Zeolite-containing remedial compositions

ABSTRACT

Methods and compositions for wellbore treating fluids, especially remedial compositions such as pills, that include zeolite and at least one carrier fluid.

CROSS-REFERENCE TO RELATED APPLICATIONS

This application is a continuation-in-part of prior application Ser. No.10/686,098 filed Oct. 15, 2003 now U.S. Pat. No. 6,964,302, the entiredisclosure of which is incorporated herein by reference, which itself isa continuation-in-part of prior application Ser. No. 10/623,443 filedJul. 18, 2003, the entire disclosure of which is incorporated herein byreference, and which itself is a continuation-in-part of priorapplication Ser. No. 10/315,415, filed Dec. 10, 2002 now U.S. Pat. No.6,989,057, the entire disclosure of which is incorporated herein byreference.

BACKGROUND

The present embodiments relate generally to wellbore treating fluidsintroduced into a subterranean zone penetrated by a wellbore,particularly fluids introduced as remedial compositions such as pills.

Conventionally, a wellbore is drilled using a drilling fluid that iscontinuously circulated down a drill pipe, through a drill bit, andupwardly through the wellbore to the surface. Typically, after awellbore has been drilled to total depth, the drill bit is withdrawnfrom the wellbore, and circulation of the drilling fluid is stopped,thereby initiating a shut-down period. The drilling fluid is left in thewellbore to provide hydrostatic pressure (i.e., hole stability) onpermeable formations penetrated by the well bore, thereby preventing theflow of formation fluids into the wellbore. Another function provided bythe drilling fluid left in the wellbore is to prevent lost circulation,by sealing off the walls of the wellbore so that the drilling fluid isnot lost into highly permeable subterranean zones penetrated by thewellbore. Sealing off the walls of the wellbore is typicallyaccomplished during the shut down period by the deposit of a filter cakeof solids from the drilling fluid, and additional dehydrated drillingfluid and gelled drilling fluid, on the walls of the wellbore.

The next operation in completing the wellbore usually involves running apipe string, e.g., casing, into the wellbore. After the pipe is run inthe wellbore, the next operation typically involves cleaning out thewellbore, which may be accomplished by re-initiating circulation ofdrilling fluid. After clean-up operations are performed in the wellbore,primary cementing operations are typically performed therein. Namely,the pipe is cemented in the wellbore by placing a cement slurry in theannulus between the pipe and the walls of the wellbore.

During any of the above or other operations performed in the wellbore, anumber of problems can occur that require remedial operations. One suchproblem is lost circulation. Lost circulation occurs when the drillingfluid is “lost” into the subterranean zone penetrated by the wellbore.The drilling fluid can be lost when the drill bit encounters spaces suchas fissures, fractures, or caverns in the subterranean zone, and thedrilling fluid flows into such spaces. Lost circulation can also occurwhen the hydrostatic pressure provided by the drilling fluid in thewellbore is compromised. This occurs when the drill bit encounters othertypes of “spaces”, such as unfavorable subterranean zones, which may becomparatively low pressure subterranean zones, such as vugs, fractures,and other thief zones, and similarly, comparatively high pressuresubterranean zones. When lost circulation occurs, remedial steps arerequired.

Most remedial steps for lost circulation comprise introducing a remedialcomposition into the wellbore to seal the above-described spaces.Examples of such remedial compositions comprise mixtures of clay andaqueous rubber latex or hydratable polymer (e.g., U.S. Pat. Nos.5,913,364; 6,060,434; 6,167,967; 6,258,757), which form masses with aconsistency often referred to as “rubbery”, “viscous”, or “gelatinous”,to seal the space. Exemplary remedial compositions form such masses uponcontact with drilling fluid, mud or other compositions with which theremedial composition is designed to react, thereby sealing fractures,fissures, low pressure or high pressure subterranean zones, and thelike. Such remedial compositions are often referred to as a “pill” bythose of ordinary skill in the art.

The present embodiments provide compositions in the form of remedialcompositions, such as pills, that comprise zeolite, as well as methodsfor the use of such remedial compositions comprising zeolite.

DESCRIPTION

According to embodiments described herein, wellbore treating fluidscomprising zeolite are introduced into a wellbore in the form of aremedial composition such as a pill. In one embodiment, the wellboretreating fluid comprises a pill comprising zeolite.

Methods according to the present embodiments provide for introducing awellbore treating fluid comprising zeolite into a subterranean zonepenetrated by a wellbore to remediate lost circulation, and to sealfissures, fractures, caverns, vugs, thief zones, low pressure or highpressure subterranean zones.

Remedial compositions that generally form a mass upon contact with adrilling fluid, mud or other composition with which the remedialcomposition is designed to react are referred to herein as a “pill”. Asused herein, the term “mud” encompasses any fluid used in hydrocarbondrilling operations, including but not limited to all types ofwater-base, oil-base and synthetic-base drilling fluids, and fluids thatcontain significant amounts of suspended solids, emulsified water oroil.

According to the present embodiments, a pill comprising zeolite and atleast one carrier fluid is provided. Pills according to the presentembodiments can be used with any methods in which conventional remedialcompositions are used. For example, a pill according to the presentembodiments can be used as a remedial composition for lost circulation.The carrier fluid can be one or more oil-based or water-based fluids asillustrated further herein. The zeolite and carrier fluid (whetherwater-based or oil-based) are referred to herein as “base components” ofthe pill to provide a point of reference for additional components suchas activators and surfactants. According to one embodiment, the zeoliteis present in an amount of from about 5 to about 75 weight percent ofthe total weight of the base components. According to other embodiments,zeolite is present in an amount of from about 20 to about 60 weightpercent of the total weight of the base components. According to stillother embodiments, zeolite is present in an amount of from about 30 toabout 50 weight percent of the total weight of the base components.

Whether the at least one carrier fluid is water-based or oil-based,embodiments of the pill herein comprise carrier fluid in an amount fromabout 25 to about 95 weight percent of the total weight of the basecomponents. According to other embodiments, carrier fluid is present inan amount of from about 40 to about 80 weight percent of the totalweight of the base components. According to still other embodiments,carrier fluid is present in an amount of from about 50 to about 70weight percent of the total weight of the base components.

When the drilling fluid, mud, or other composition with which the pillcomprising zeolite is desired to react is water-based, then the pillcomprises zeolite and at least one oil-based carrier fluid.Alternatively, the carrier fluid is a synthetic-based fluid. When suchoil-based (or synthetic-based) pill is introduced into the wellbore, itwill react when it comes into contact with the water-based fluid,thereby forming a mass.

According to another embodiment, when the drilling fluid, mud or othercomposition with which the pill comprising zeolite is desired to reactis oil-based or synthetic-based, then the pill comprises zeolite and atleast one water-based carrier fluid. Thus, when such water-based pill isintroduced into the wellbore, it will react when it comes into contactwith the oil-based or synthetic-based drilling fluid, thereby forming amass.

According to yet another embodiment, when the pill comprising zeolite isoil-based or synthetic-based, or when the drilling fluid, mud orcomposition with which the pill is desired to react is oil-based orsynthetic-based, the pill further comprises at least one surfactant.Surfactants are known to those of ordinary skill in the art, and theselection of a type and concentration of a surfactant largely depends onthe nature and composition of the pill, which can be determined by thoseof ordinary skill in the art. Suitable surfactants for use with thepresent embodiments include but are not limited tocetyltrimethylammonium chloride, cocoaalkyltrimethylammonium chloride,cocoalkyldimethylbenzyl ammonium chloride, stearyltrimethlyammoniumchloride, alkylbehenyltrimethylammonium chloridedihydrogenatedtallowalkylethylmethyleammonium ethosulfate,didecyldimethylammonium chloride, dicocyldimethylammonium chloride,distearyldimethylammonium chloride, dioleyldimethylammonium chloride,trilaurylmethylammonium chloride,cocoyl-bis-(2-hydroxyethyl)methylammonium chloride, polyoxyethylene (15)cocoalkylmethylammonium chloride, olyel-bis-(2-hydroxyethyl)methylammonium chloride, tallowalkylmethylpropylenediammoniumdichloride, and trimethyltallowammonium chloride. According to oneembodiment illustrated herein, a remedial composition comprising zeoliteand at least one carrier fluid further comprises trimethyltallowammoniumchloride as a surfactant.

According to still other embodiments, an activator is incorporated intothe pills of the present embodiments in an amount of from about 1 toabout 20 weight percent based on the total weight of the base componentsof the pill. The activator can be any of calcium hydroxide, sodiumsilicate, sodium fluoride, sodium silicofluoride, magnesiumsilicofluoride, zinc silicofluoride, sodium carbonate, potassiumcarbonate, sodium hydroxide, potassium hydroxide, sodium sulfate, andmixtures thereof. Selection of type and concentration of an activator(s)largely depends on the nature and composition of the pill. Typically,the activator is selected so that it will add strength to the massformed when the pill is contacted with a drilling fluid, mud, or othercomposition with which it is designed to react. According to oneembodiment, the activator is calcium hydroxide (commonly referred to aslime).

As described above, conventional pills comprise materials that form amass upon contact with the drilling fluid, mud or other composition withwhich the pill is designed to react, thereby sealing spaces such asfissures, fractures, caverns, vugs, thief zones, low pressure or highpressure subterranean zones and preventing lost circulation. Pillscomprising zeolite according to embodiments presented herein developcompressive strength over time, which results in an enhanced sealing ofsuch spaces. Moreover, the sealing of such spaces according to thepresent embodiments strengthens the wellbore formation such that higherdensity muds, drilling fluids, and other wellbore treating fluids can bepumped through the wellbore without compromising the stability of thewellbore.

Zeolites are porous alumino-silicate minerals that may be either anatural or manmade material. Manmade zeolites are based on the same typeof structural cell as natural zeolites, and are composed ofaluminosilicate hydrates having the same basic formula as given below.It is understood that as used in this application, the term “zeolite”means and encompasses all natural and manmade forms of zeolites. Allzeolites are composed of a three-dimensional framework of SiO₄ and AlO₄in a tetrahedron, which creates a very high surface area. Cations andwater molecules are entrained into the framework. Thus, all zeolites maybe represented by the crystallographic unit cell formula:M_(a/n)[(AlO₂)_(a)(SiO₂)_(b]·) xH₂Owhere M represents one or more cations such as Na, K, Mg, Ca, Sr, Li orBa for natural zeolites and NH₄, CH₃NH₃, (CH₃)₃NH, (CH₃)₄N, Ga, Ge and Pfor manmade zeolites; n represents the cation valence; the ratio of b:ais in a range from greater than or equal to 1 and less than or equal to5; and x represents the moles of water entrained into the zeoliteframework.

Preferred zeolites for use in the wellbore treating fluids of thepresent embodiments include analcime (hydrated sodium aluminumsilicate), bikitaite (lithium aluminum silicate), brewsterite (hydratedstrontium barium calcium aluminum silicate), chabazite (hydrated calciumaluminum silicate), clinoptilolite (hydrated sodium aluminum silicate),faujasite (hydrated sodium potassium calcium magnesium aluminumsilicate), harmotome (hydrated barium aluminum silicate), heulandite(hydrated sodium calcium aluminum silicate), laumontite (hydratedcalcium aluminum silicate), mesolite (hydrated sodium calcium aluminumsilicate), natrolite (hydrated sodium aluminum silicate), paulingite(hydrated potassium sodium calcium barium aluminum silicate),phillipsite (hydrated potassium sodium calcium aluminum silicate),scolecite (hydrated calcium aluminum silicate), stellerite (hydratedcalcium aluminum silicate), stilbite (hydrated sodium calcium aluminumsilicate) and thomsonite (hydrated sodium calcium aluminum silicate).Most preferably, the zeolites for use in the wellbore treating fluids ofthe present embodiment include chabazite and clinoptilolite.

Carrier fluids suitable for use in the embodiments of wellbore treatingfluids disclosed herein comprise an aqueous fluid, such as water andwater-based gels, oil-based and synthetic-based fluids, emulsions,acids, or mixtures thereof. Exemplary oil-based fluids include but arenot limited to canola oil, kerosene, diesel oil, fish oil, mineral oil,sunflower oil, corn oil, soy oil, olive oil, cottonseed oil, peanut oiland paraffin. Exemplary synthetic-based fluids include but are notlimited to esters, olefins and ethers.

The preferred carrier fluid depends upon the properties desired for thewellbore treating fluid, as well as the cost, availability, temperature,stability, viscosity, clarity, and the like, of the carrier fluid. Whenthe carrier fluid comprises water, the water can be fresh water,unsaturated salt solution, including brines and seawater, and saturatedsalt solution.

In carrying out the methods of the present embodiments, drillingoperations include drilling a wellbore with a mud, introducing awellbore treating fluid comprising zeolite and at least one carrierfluid into the wellbore, and forming a mass in the wellbore by allowingthe wellbore treating fluid to come into contact with the mud.

Other methods according to the present embodiments include methods forperforming remedial operations in a wellbore by introducing a wellboretreating fluid comprising zeolite and a carrier fluid into the wellbore,allowing the wellbore treating fluid to come into contact with a mudresiding in at least one space in the wellbore such as a fissure,fracture, cavern, vug, thief zone, low pressure or high pressuresubterranean zone, whereby the wellbore treating fluid forms a mass andseals the space.

The following examples are illustrative of the foregoing methods andcompositions.

EXAMPLE 1

Three water-based muds, (Muds 1, 2, and 3), one oil-based mud, (Mud 4)and one synthetic-based mud (Mud 5), were obtained from BaroidIndustrial Drilling Products. Muds 1–5 were obtained from Baroid alreadyprepared, however the components of each mud, and the amount of each,are identified in Table 1A.

The precise chemical identification of the ester in Mud 5 obtained fromBaroid is not known. However, the ester can generally be described as amonocarboxylic acid ester of a C₂–C₁₂ monofunctional alkanol, whereinthe monocarboxylic acid contains from 12 to 16 carbon atoms and isaliphatically saturated. Such esters are described in U.S. Pat. No.5,252,554, issued Oct. 12, 1993 to Mueller et al. and assigned to BaroidLimited.

In addition, the precise chemical description of the followingcomponents identified in Table 1A is not known, however the function ofeach component is provided as follows: BARAZAN PLUS is a suspensionagent/viscosifier that includes xanthan gum; EZ-MUD is a shalestabilizing polymer solution; INVERMUL, EZ-MUL, and EZ-MUL NTE areemulsifiers; GELTONE II and GELTONE V are viscosifiers; and DURATONE HTis a filtration control agent. The amount of each component is reportedin Table 1A in “lb/bbl”, which indicates pounds of component per barrelof mud.

Two oil-based pills comprising zeolite (Pills 1 and 2) were prepared bypouring the amount of canola oil and kerosene indicated in Table 1B intoa measuring cylinder, sealing it and then shaking it back and forth byhand to form an oil mixture. The oil mixture was then poured into aWaring blender and Arquad T-50™ surfactant was added in the amountreported in the table. Arquad T-50™ is a trimethyltallowammoniumchloride (50% active) surfactant that is commercially available fromArmak Industrial Chemicals Division. The zeolite, and lime whereindicated, were added to the blender over a period of 30 seconds at ablender speed of 2000 rpm. Mixing was then continued until a homogenousmix was obtained, which took approximately 1 minute.

Two water-based pills comprising zeolite (Pills 3 and 4) were preparedby adding the zeolite, and lime where indicated, to water in a Waringblender over a period of 30 seconds at 2000 rpm. Mixing was thencontinued until a homogenous mix was obtained, which took approximately1 minute.

The amounts of zeolite, canola oil, kerosene and water (as applicable)used to prepare Pills 1–4 are reported in the table as a weight percent(“wt. %”), while the amounts of lime and surfactant (as applicable) arereported as a weight percent of the total weight of the “basecomponents” (“wt. % base”). The zeolite, canola oil, kerosene and waterare referred to in the table as “base components” merely to provide apoint of reference for the amount of lime and surfactant used to preparePills 1–4. Similarly, the lime and surfactant are referred to in thetable as “additives” merely to illustrate that the amount of thesecomponents is calculated based on the total weight of the zeolite,canola oil, kerosene and water. The zeolite used to prepare Pills 1–4was chabazite, which is commercially available from C2C ZeoliteCorporation of Calgary, Canada.

TABLE 1A Mud 1 Mud 2 Mud 3 Mud 4 Mud 5 Components Water Water Water OilSynthetic (lb/bbl) Based Based Based Based Based Bentonite 15 22 15 0 0Caustic soda 0.75 0.75 0.75 0 0 BARAZAN PLUS 0.5 0 0.5 0 0 Lime 0 1.0 03.0 1.0 EZ-MUD 0 0 8.93 0 0 Barite 118 117 118 0 816 Water 36.5 37.736.5 0 0 Diesel 0 0 0 26.8 0 Ester 0 0 0 0 20.8 2% CaCl₂ Solution 0 0 06.7 5.2 INVERMUL 0 0 0 7 0 EZ-MUL 0 0 0 1.5 0 EZ-MUL NTE 0 0 0 0 12GELTONE II 0 0 0 1.5 0 GELTONE V 0 0 0 0 1.0 DURATONE HT 0 0 0 0 10

TABLE 1B Pill 1 Pill 2 Pill 3 Pill 4 Oil Based Oil Based Water BasedWater Based Base Components (wt. %) Zeolite (Chabazite) 46.0 37.6 48.037.6 Canola Oil 32.4 37.6 0 0 Kerosene 21.6 24.8 0 0 Water 0 0 52.0 62.4Additives (wt. % Base) Hydrated Lime 0 10.8 0 10.8 Arquad T-50 0 0.48 00

Pills 1–4 were then blended by hand with Muds 1–5 to form ten samplecompositions, as indicated in Table 1C. Prior to blending with a pill,each mud was stirred at low speed with a Series 2000, Model 50 variablespeed laboratory dispersator mixer available from Premier Mill Corp. togive a uniform suspension. When the sample was prepared from anoil-based or synthetic-based mud, 100 mL of the indicated mud (i.e., Mud4 or 5) was placed in a cylindrical plastic container and 100 mL of theindicated water based zeolite pill (i.e., Pill 3 or 4) was added. Whenthe sample was prepared from a water-based mud, the same procedure wasfollowed. Namely, 100 mL of the indicated mud (i.e., Mud 1, 2, or 3) wasplaced in a cylindrical plastic container and 100 mL of the indicatedoil based zeolite pill (i.e., Pill 1 or 2) was added. For each of theten samples, the plastic container was sealed with a cap, and then handshaken for from about 30 seconds to about 1 minute, by which time thesample had turned into a mass, as reported in Table 1C. The consistencyof each mass was similar to the consistency of the masses formed byconventional pills, which is often referred to as “rubbery”, “viscous”,or “gelatinous”.

TABLE 1C Sample No. and Blend Composition Result Sample 1: Pill 1 + Mud1 mass Sample 2: Pill 1 + Mud 2 mass Sample 3: Pill 1 + Mud 3 massSample 4: Pill 2 + Mud 1 mass Sample 5: Pill 2 + Mud 2 mass Sample 6:Pill 2 + Mud 3 mass Sample 7: Pill 3 + Mud 4 mass Sample 8: Pill 3 + Mud5 mass Sample 9: Pill 4 + Mud 4 mass Sample 10: Pill 4 + Mud 5 mass

The results of Table 1C illustrate that remedial compositions comprisingzeolite, such as Pills 1–4, are suitable for use in any methods in whicha conventional remedial composition is used to form a mass. For example,the present embodiments can be used in drilling operations and remedialoperations in wellbores where a mass is formed for purposes such assealing fissures, fractures, caverns, vugs, thief zones, low pressuresubterranean zones and high pressure subterranean zones. Further still,Table 1C illustrates that remedial compositions comprising zeolite, suchas Pills 1–4, can be either water-based or oil-based, and can be usedwith conventional water-based or oil-based muds.

As reported in Table 1B, Pills 2 and 4 included hydrated lime. Todetermine whether the hydrated lime added strength to the mass,compressive strength measurements were taken for each sample thatincluded either Pill 2 or Pill 4, namely, Samples 4–6 and 9–10. Thecompressive strengths of Samples 4–6 and 9–10 were determined by placingthe sealed plastic containers used to gather the data reported in Table1C in a water bath at 180° F. and atmospheric pressure for the timeperiods reported in Table 1D. The plastic containers were then removedfrom the water bath, allowed to cool and the cylindrical samples weredemolded from each plastic container. The top end of each cylindricalsample was cut using a tile saw to give a smooth and level surface. Theremainder of the sample was then placed in a Tineus Olsen universaltesting machine and the compressive strength determined according tooperating procedures for the universal testing machine. The compressivestrength measurements are reported in Table 1D.

TABLE 1D Compressive strength (psi) Measured at 180° F. and at Time(Days) Sample No. 5 days 10 days 15 days 20 days Sample 4  0 0 25 25Sample 5  0 0 25 25 Sample 6  0 0 15 15 Sample 9  27.1 26.8 not takennot taken Sample 10 212 164 not taken not taken

The compressive strength data indicates that wellbore treating fluidscomprising zeolite and an activator, such as the remedial compositionsof Pills 2 and 4, form masses that develop compressive strength. Suchremedial compositions are suitable for use in methods of performingdrilling operations and performing remedial operations. In theembodiments illustrated by Pills 2 and 4, the activator comprised lime(also known as “calcium hydroxide”). According to other embodiments, theactivator is any of sodium silicate, sodium fluoride, sodiumsilicofluoride, magnesium silicofluoride, zinc silicofluoride, sodiumcarbonate, potassium carbonate, sodium hydroxide, potassium hydroxide,sodium sulfate, and mixtures thereof.

In practicing methods of the present embodiments, a remedial compositioncomprising zeolite, such as Pills 1–4, is introduced into a wellbore andallowed to come into contact with a mud residing in a space such as afissure, fracture, cavern, vug, thief zone, low pressure subterraneanzone or high pressure subterranean zone in the wellbore. When theremedial composition contacts the mud, a mass forms, thereby sealing thespace and preventing problems such as lost circulation. Moreover, thesealing of such spaces strengthens the wellbore formation such thathigher density muds, drilling fluids, and other wellbore treating fluidscan be pumped through the wellbore without compromising the stability ofthe wellbore.

While the embodiments described herein relate to wellbore treatingfluids provided as remedial compositions such as pills, it is understoodthat any wellbore treating fluids such as drilling, completion andstimulation fluids including, but not limited to, drilling muds, cementcompositions, well cleanup fluids, workover fluids, spacer fluids,gravel pack fluids, acidizing fluids, fracturing fluids, conformancefluids, spotting fluids and the like can be prepared using zeolite and acarrier fluid. Accordingly, improved methods of the present inventioncomprise preparing a wellbore treating fluid using at least one carrierfluid and zeolite, as previously described herein, and placing the fluidin a subterranean formation. Other methods according to the presentembodiments include performing drilling operations, completing and/orstimulating a subterranean formation, and performing primary cementingoperations using a wellbore treating fluid comprising zeolite and atleast one carrier fluid.

Other embodiments of the current invention will be apparent to thoseskilled in the art from a consideration of this specification orpractice of the embodiments disclosed herein. However, the foregoingspecification is considered merely exemplary of the present invention,with the true scope and spirit of the invention being indicated by thefollowing claims.

1. A method of performing drilling operations comprising: drilling awellbore with a mud; introducing a wellbore treating fluid comprisingzeolite and at least one carrier fluid into the wellbore; and forming amass in the wellbore by allowing the wellbore treating fluid to comeinto contact with the mud in the wellbore.
 2. The method of claim 1wherein the zeolite is represented by the formula:M_(a/n)[(AlO₂)_(a)(SiO₂)_(b]·) xH₂O where M represents one or morecations selected from the group consisting of Na, K, Mg, Ca, Sr, Li, Ba,NH₄, CH₃NH₃, (CH₃)₃NH, (CH₃)₄N, Ga, Ge and P; n represents the cationvalence; the ratio of b:a is in a range from greater than or equal to 1and less than or equal to 5; and x represents the moles of waterentrained into the zeolite framework.
 3. The method of claim 1, whereinthe zeolite is selected from the group consisting of analcime,bikitaite, brewsterite, chabazite, clinoptilolite, faujasite, harmotome,heulandite, laumontite, mesolite, natrolite, paulingite, phillipsite,scolecite, stellerite, stilbite, and thomsonite.
 4. The method of claim1 wherein the mud is a water-based mud.
 5. The method of claim 4 whereinthe at least one carrier fluid comprises an oil-based carrier fluid. 6.The method of claim 5 wherein the at least one carrier fluid comprisesone or more oils selected from the group consisting of diesel, canola,kerosene, diesel oil, fish oil, mineral oil, sunflower oil, corn oil,soy oil, olive oil, cottonseed oil, peanut oil and paraffin.
 7. Themethod of claim 4 wherein the at least one carrier fluid comprises asynthetic-based carrier fluid.
 8. The method of claim 1 wherein the massseals at least one space in the wellbore selected from the groupconsisting of fissures, fractures, caverns, vugs, thief zones, lowpressure subterranean zones, and high pressure subterranean zones. 9.The method of claim 1 wherein the mud is one of a synthetic-based mudand an oil-based mud.
 10. The method of claim 9 wherein the at least onecarrier fluid comprises a water-based carrier fluid.
 11. The method ofclaim 10 wherein the at least one carrier fluid is selected from thegroup consisting of water and water-based gels.
 12. The method of claim10 wherein the at least one carrier fluid is selected from the groupconsisting of fresh water, unsaturated salt solution, brine, seawater,and saturated salt solution.
 13. The method of claim 1 wherein the atleast one carrier fluid is present in the wellbore treating fluid in anamount of from about 25% to about 95% by weight.
 14. The method of claim1 wherein the forming of the mass further comprises allowing thewellbore treating fluid to come into contact with mud residing in atleast one space in the wellbore such that the mass seals the space. 15.The method of claim 14 wherein the at least one space in the wellbore isselected from the group consisting of fissures, fractures, caverns,vugs, thief zones, low pressure subterranean zones, and high pressuresubterranean zones.
 16. The method of claim 1 wherein the wellboretreating fluid comprises zeolite in an amount of from about 5% to about75% by weight.
 17. The method of claim 16 wherein the wellbore treatingfluid comprises zeolite in an amount of from about 20% to about 60% byweight.
 18. The method of claim 17 wherein the wellbore treating fluidcomprises zeolite in an amount of from about 30% to about 50% by weight.19. The method of claim 1 wherein the wellbore treating fluid furthercomprises an activator.
 20. The method of claim 19 wherein the activatoris present in the wellbore treating fluid in an amount of from about 1%to about 20% by weight, based on the total weight of the zeolite and theat least one carrier fluid.
 21. The method of claim 20 wherein theactivator is selected from the group consisting of calcium hydroxide,sodium silicate, sodium fluoride, sodium silicofluoride, magnesiumsilicofluoride, zinc silicofluoride, sodium carbonate, potassiumcarbonate, sodium hydroxide, potassium hydroxide, sodium sulfate, andmixtures thereof.
 22. The method of claim 21 wherein the activatorcomprises calcium hydroxide in an amount of from about 1 to about 20weight percent of the total weight of the zeolite and the carrier fluid.23. The method of claim 1 wherein the wellbore treating fluid furthercomprises a surfactant.
 24. The method of claim 23 wherein thesurfactant is selected from the group consisting ofcetyltrimethylammonium chloride, cocoaalkyltrimethylammonium chloride,cocoalkyldimethylbenzyl ammonium chloride, stearyltrimethlyammoniumchloride, alkylbehenyltrimethylammonium chloridedihydrogenatedtallowalkylethylmethyleammonium ethosulfate,didecyldimethylammonium chloride, dicocyldimethylammonium chloride,distearyldimethylammonium chloride, dioleyldimethylammonium chloride,trilaurylmethylammonium chloride,cocoyl-bis-(2-hydroxyethyl)methylammonium chloride, polyoxyethylene (15)cocoalkylmethylammonium chloride, olyel-bis-(2-hydroxyethyl)methylammonium chloride, tallowalkylmethyipropylenediammoniumdichloride, and trimethyltallowammonium chloride.
 25. A method ofperforming remedial operations in a wellbore penetrating a subterraneanzone comprising: introducing a wellbore treating fluid comprisingzeolite and at least one carrier fluid into the wellbore; forming a massin the wellbore by allowing the wellbore treating fluid to come intocontact with a mud residing in at least one space in the wellbore; andsealing the at least one space in the wellbore with the mass.
 26. Themethod of claim 25 wherein the at least one space in the wellbore isselected from the group consisting of fissures, fractures, caverns,vugs, thief zones, low pressure subterranean zones, and high pressuresubterranean zones.
 27. The method of claim 25 wherein the zeolite isrepresented by the formula:M_(a/n)[(AlO₂)_(a)(SiO₂)_(b]·) xH₂O where M represents one or morecations selected from the group consisting of Na, K, Mg, Ca, Sr, Li, Ba,NH₄, CH₃NH₃, (CH₃)₃NH, (CH₃)₄N, Ga, Ge and P; n represents the cationvalence; the ratio of b:a is in a range from greater than or equal to 1and less than or equal to 5; and x represents the moles of waterentrained into the zeolite framework.
 28. The method of claim 25,wherein the zeolite is selected from the group consisting of analcime,bikitaite, brewsterite, chabazite, clinoptilolite, faujasite, harmotome,heulandite, laumontite, mesolite, natrolite, paulingite, phillipsite,scolecite, stellerite, stilbite, and thomsonite.
 29. The method of claim25 wherein the mud is a water-based mud.
 30. The method of claim 29wherein the at least one carrier fluid comprises an oil-based carrierfluid.
 31. The method of claim 30 wherein the at least one carrier fluidcomprises one or more oils selected from the group consisting of diesel,canola, kerosene, diesel oil, fish oil, mineral oil, sunflower oil, cornoil, soy oil, olive oil, cottonseed oil, peanut oil and paraffin. 32.The method of claim 30 wherein the at least one carrier fluid comprisesa synthetic-based carrier fluid.
 33. The method of claim 25 wherein themud is one of an oil-based mud and a synthetic-based mud.
 34. The methodof claim 33 wherein the at least one carrier fluid comprises awater-based carrier fluid.
 35. The method of claim 33 wherein the atleast one carrier fluid is selected from the group consisting of waterand water-based gels.
 36. The method of claim 33 wherein the at leastone carrier fluid is selected from the group consisting of fresh water,unsaturated salt solution, brine, seawater, and saturated salt solution.37. The method of claim 25 wherein the at least one carrier fluid ispresent in the wellbore treating fluid in an amount of from about 25% toabout 95% by weight.
 38. The method of claim 25 wherein the wellboretreating fluid comprises zeolite in an amount of from about 5% to about75% by weight.
 39. The method of claim 38 wherein the wellbore treatingfluid comprises zeolite in an amount of from about 20% to about 60% byweight.
 40. The method of claim 39 wherein the wellbore treating fluidcomprises zeolite in an amount of from about 30% to about 50% by weight.41. The method of claim 25 wherein the wellbore treating fluid furthercomprises an activator.
 42. The method of claim 41 wherein the activatoris present in the wellbore treating fluid in an amount of from about 1%to about 20% by weight, based on the total weight of the zeolite and theat least one carrier fluid.
 43. The method of claim 41 wherein theactivator is selected from the group consisting of calcium hydroxide,sodium silicate, sodium fluoride, sodium silicofluoride, magnesiumsilicofluoride, zinc silicofluoride, sodium carbonate, potassiumcarbonate, sodium hydroxide, potassium hydroxide, sodium sulfate, andmixtures thereof.
 44. The method of claim 43 wherein the activatorcomprises calcium hydroxide in an amount of from about 1 to about 20weight percent of the total weight of the zeolite and the carrier fluid.45. The method of claim 25 wherein the wellbore treating fluid furthercomprises a surfactant.
 46. The method of claim 45 wherein thesurfactant is selected from the group consisting ofcetyltrimethylammonium chloride, cocoaalkyltrimethylammonium chloride,cocoalkyldimethylbenzyl ammonium chloride, stearyltrimethlyammoniumchloride, alkylbehenyltrimethylammonium chloridedihydrogenatedtallowalkylethylmethyleammonium ethosulfate,didecyldimethylammonium chloride, dicocyldimethylammonium chloride,distearyldimethylammonium chloride, dioleyldimethylammonium chloridetrilaurylmethylammonium chloride,cocoyl-bis-(2-hydroxyethyl)methylammonium chloride, polyoxyethylene (15)cocoalkylmethylammonium chloride, olyel-bis-(2-hydroxyethyl)methylammonium chloride, tallowalkylmethylpropylenediammonium dichionde,and trimethyltallowammonium chloride.
 47. A method of performingoperations in a wellbore comprising: introducing a wellbore treatingfluid comprising zeolite and at least one of an oil-based carrier fluidand a synthetic-based carrier fluid into the wellbore; and forming amass in the wellbore by allowing the wellbore treating fluid to comeinto contact with a water-based mud residing in the wellbore.
 48. Themethod of claim 47 wherein the zeolite is represented by the formula:M_(a/n)[(AlO₂)_(a)(SiO₂)_(b]·) xH₂O where M represents one or morecations selected from the group consisting of Na, K, Mg, Ca, Sr, Li, Ba,NH₄, CH₃NH₃, (CH₃)₃NH, (CH₃)₄N, Ga, Ge and P; n represents the cationvalence; the ratio of b:a is in a range from greater than or equal to 1and less than or equal to 5; and x represents the moles of waterentrained into the zeolite framework.
 49. The method of claim 47 whereinthe zeolite is selected from the group consisting of analcime,bikitaite, brewsterite, chabazite, clinoptilolite, faujasite, harmotome,heulandite, laumontite, mesolite, natrolite, paulingite, phillipsite,scolecite, stellerite, stilbite, and thomsonite.
 50. The method of claim47 wherein the oil-based carrier fluid comprises one or more oilsselected from the group consisting of diesel, canola, kerosene, fish,mineral, sunflower, corn, soy, olive, cottonseed, peanut and paraffin.51. The method of claim 47 further comprising: drilling the wellborewith the water-based mud prior to introducing the wellbore treatingfluid.
 52. The method of claim 47 wherein the water-based mud isresiding in at least one space in the wellbore, and the forming of themass seals the at least one space.
 53. The method of claim 52 whereinthe at least one space is selected from the group consisting offissures, fractures, caverns, vugs, thief zones, low pressuresubterranean zones, and high pressure subterranean zones.
 54. The methodof claim 47 wherein the wellbore treating fluid comprises zeolite in anamount selected from about 5% to about 75% by weight, about 20% to about60% by weight, and about 30% to about 50% by weight.
 55. The method ofclaim 47 wherein the wellbore treating fluid further comprises anactivator.
 56. The method of claim 55 wherein the activator is selectedfrom the group consisting of calcium hydroxide, sodium silicate, sodiumfluoride, sodium silicofluoride, magnesium silicofluoride, zincsilicofluoride, sodium carbonate, potassium carbonate, sodium hydroxide,potassium hydroxide, sodium sulfate, and mixtures thereof.
 57. Themethod of claim 47 wherein the wellbore treating fluid further comprisesa surfactant.
 58. The method of claim 57 wherein the surfactant isselected from the group consisting of cetyltrimethylammonium chloride,cocoaalkyltrimethylammonium chloride, cocoalkyldimethylbenzyl ammoniumchloride, stearyltrimethlyammonium chloride,alkylbehenyltrimethylammonium chloridedihydrogenatedtallowalkylethylmethyleammonium ethosulfate,didecyldimethylammonium chloride, dicocyldimethylammonium chloride,distearyldimethylammonium chloride, dioleyldimethylammonium chloride,trilaurylmethylammonium chloride,cocoyl-bis-(2-hydroxyethyl)methylammonium chloride, polyoxyethylene (15)cocoalkylmethylammonium chloride, olyel-bis-(2-hydroxyethyl)methylammonium chloride, tallowalkylmethylpropylenediammoniumdichloride, and trimethyltallowammonium chloride.